Projects

Oil & Gas

DEVILS CREEK (APACHE Energy)

The Devil Creek Development Project (DCDP) is a proposed green field gas development project 40 km southwest of Dampier in Western Australia.

an unmanned offshore gas production platform;
an offshore gas supply pipeline;
an onshore gas supply pipeline;
a gas processing plant, and
a sales gas export pipeline.

DCDP gas will initially be extracted from the Reindeer field and brought to the mainland via a 110 km offshore and onshore gas supply pipeline to the Devil Creek Gas Plant.

The offshore gas supply pipeline will cross the mainland in the vicinity of Forty Mile Beach, some 42 km southwest of Dampier.

The raw natural gas will be processed and then supplied into the Dampier to Bunbury Natural Gas (DBNG) pipeline. A second commercial product derived from the gas stream will be gas condensate, which is to be exported south from the Project area via heavy haulage trailers along the North West Coastal Highway (NWCH) and further south to Kwinana.

The DCDP will initially provide up to 100 million standard cubic feet per day (MMSCFD) of dry natural gas and 80 kl per day of gas condensate, however the facilities will be designed to process up to 200 MMSCFD and 160 kl per day of condensate.

The proposed location of the Devil Creek Gas Plant is in the immediate vicinity of the North West Coastal Highway (NWCH) approximately 10 km inland from the Forty Mile Beach. The proposed location for the gas plant is on Mardie Station pastoral lease, currently open and generally unused pastoral land. It is also proposed that there will be accommodation facilities for construction workers and gas plant personnel in the vicinity of the Devil Creek Well on land that is currently part of the Mardie Station pastoral lease.

Blacktip

Blacktip gas field is located in the Timor Sea approximately 110 km off the shore of Northern Australia in the Bonaparte Basin, at a water depth of some 50 meters. The Blacktip field is fully owned and operated by Eni and has recoverable reserves of 150 million boe.

The project provides for the drilling of 2 initial development wells, the installation of a production platform, the laying of a 108-kilometer long offshore pipeline and the construction of an onshore treatment plant with a capacity of 1.3 billion cubic meters per year.

The gas drilled from Blacktip field will be mainly used to generate electricity in Darwin and other Northern Territory locations, through a 25-year Gas Sales Agreement with Power Water Corporation.

Saipem was awarded the EPIC contract encompassing the engineering, procurement, construction, installation and pre-commissioning of the wellhead platform and the 108 kilometre export pipeline system. Saipem's installation vessel Castoro Otto will be utilised for marine activities through the third quarter of 2008.

Australian offshore builder AusGroup, better known as Ausclad, was awarded a sub-contract to build the wellhead platform. Work on the A$26 million to A$28 million (US$21.3 million to US$22.9 million) contract is scheduled for completion in late 2008. Work includes the jacket, topside modules and piles. The platform will be built at the Australian Marine Complex.

EPC Onshore Gas Plant Civil Works Contract has been awarded to McMahons Darwin. Production is planned to start in 2009 at an initial annual rate of 650 million cubic meters, increasing to 1.1 billion cubic meters.

INPEX Browse holds the Ichthys field (76%, INPEX, 24% Total) in the Browse Basin, off the northern tip of WA. They have proven up resources to justify an LNG plant, have just completed Pre-FEED studies and are moving into the FEED and execution phase. During the FEED period they need to kick off pre-mobilisation and infrastructure work and want to do this through a contract which will incorporate execution of the Maret Islands support infrastructure at the earliest possible time in the development, (ie immediately access approval is obtained).

INPEX has a share of Indonesia's Bontang LNG which it sells to Japanese customers. As a designated national flag company with advantageous access to desirable projects through diplomacy of energy resources by the Japanese Government, INPEX is working to ensure the stable and efficient supply of energy to Japan. The development is valued at over A$8Bn.

Blacktip

The gas drilled from Blacktip field will be mainly used to generate electricity in Darwin and other Northern Territory locations, through a 25-year Gas Sales Agreement with Power Water Corporation.

Crux

The Crux field lies in 190 metres of water in the Timor Sea approximately 700 km from Darwin and 600 km from Broome. Crux is 110km south-west of the producing Challis oil field. The Crux-1 well intersected a massive 240 metre gross gas column in high quality sandstone reservoirs. Two Drill Stem Tests (DST's) were conducted on the well with each zone flowing at rates in excess of 30 million standard cubic feet per day (mmscf/d). The gas is estimated to contain approximately 28 barrels of condensate in each million cubic feet of gas. Initial processing and interpretation of survey data indicates that the field contains a best estimate contingent condensate resource of 71 million barrels of condensate.

The Crux-2 well intersected a gross gas column of 158 meters yielding a net gas pay zone of 102 meters. The total gas column was significantly greater than pre-drill estimates due to the intersection of an additional 73 meters (22 meters net) of a younger formation with excellent reservoir properties. This gas bearing formation was not seen in the Crux-1 well. These results confirm the extension of the high quality reservoir sands seen in the Crux-1 well to the northeastern part of the field (as predicted from the similarity in seismic character at the sidetrack location) and increase confidence in the resource volumes.

In 2006, Nexus sold the rights to the gas (excluding condensate) in the Crux field to Shell for US$40 million (A$53 million). The agreement provides for Nexus to be able to execute its condensate recycle project until 31 December 2020 at which time Shell will take ownership of the permit and would be able to extract the gas and any remaining condensate.

Field development planning to date has concentrated on a gas recycling scheme producing approximately 600 mmscf/d of gas through two production wells and stripping about 17,000 barrels a day of condensate. The condensate would then be stored on a Floating Production Storage and Offtake (FPSO) facility, transferred to trading crude oil tankers and sold to refineries in the Asian region. The dry gas would be re-injected into the reservoir through three gas injection wells. In this way approximately 90% of the condensate in place, around 48 million barrels (bbls), could be recovered.

Front End Engineering and Design (FEED) of a gas condensate recycling project (Crux liquids project) is underway with Mustang Engineering. FEED for the liquids project is expected to be completed in January 2007 potentially enabling Nexus to be in a position to sanction the project by the end of Q2 2007 with first condensate being produced in the middle of 2009.

Woollybutt South Lobe

Eni and its partners in the Woollybutt joint venture have decided to develop the southern lobe of the Woollybutt oilfield located in the WA-25-L Production Licence in Carnarvon basin off Western Australia in 100m water depth. The Woollybutt South Lobe is located approximately 5 kilometres south of the currently producing Woollybutt North Lobe.

The A$180 million (US$142.3 million) Woollybutt South development will see two horizontal production wells tied back through subsea flexible flowlines to the Four Vanguard FPSO. The wells will be a re-entry of the Woollybutt-4 well, which had confirmed the presence of oil in the southern lobe of the field, and the Woollybutt-6 appraisal well. Drilling is expected to start in the middle of 2007 with first production scheduled to start in early 2008.

JDR Umbilical Systems has been awarded the umbilical supply contract from its Asia Pacific facility in Thailand. Two umbilicals are totalling approximately 9km in length will be tied back to existing subsea facilities. A specialized electric cable, designed by JDR to mitigate against gas permeation into the conductors, will be incorporated into the umbilical.

Woollybutt is currently producing about 11,000 barrels per day of oil. The Woollybutt-4 well is expected to boost production by around 10,000 bpd. WA-25- L Joint Venture Participants are:

Eni Australia Ltd (Operator) 65%, Tap West Pty Ltd 15%, Mobil Australia Resource Co Pty Ltd 20%.

Dampier Bunbury Pipeline Expansion

Dampier Bunbury Pipeline (DBP) will go-ahead with a $700 million expansion of the Dampier to Bunbury Natural Gas Pipeline (DBNGP). The Stage 5A expansion is the second major expansion of the DBNGP since the consortium of owners took over the pipeline in October 2004. As with the Stage 4 expansion, all the additional capacity will be fully contracted to new and existing shippers under long term arrangements.

Combined, the Stage 4 and Stage 5A expansions represent an investment of about $1.13 billion in the pipeline. Construction of this latest expansion is expected to begin early next year with the first capacity to be commissioned during the first quarter of 2008, with the balance by the third quarter of the same year. The expansion will increase production by about 100 terajoules per day (TJ/d).

Stage 5A comprises the laying of additional pipe alongside the existing pipeline in a process known as looping. Stage 5A comprises ten loops totalling in excess of 570 km. Stage 5A will be the first of a proposed 3 part expansion of the pipeline, known as the Stage 5 expansion. Timing of Stages 5B and 5C is dependant on a range of issues, including the price and availability of gas to support new resource processing and power generation developments.

Saipem has been awarded the turn-key contract for the the design, construction, installation and pre-commissioning activities of the Stage 5A expansion. JFE Steel Corporation and Metal One Corporation have been appointed as the sole suppliers of line pipe for the expansion project. The two companies will supply approximately 82,000MT of 26" OD API 5L X-70 Line Pipe to DBNGP (WA) from October-November 2006.

Dampier Bunbury Pipeline is the trading name of the DBNGP group of companies, ultimately owned by the consortium that purchased the Dampier to Bunbury Natural Gas Pipeline in October 2004. DBP is majority owned by DUET – Diversified Utility and Energy Trusts - with Alcoa and Alinta minority owners.

Montara

Coogee Resources will develop the A$450 million Montara Project via an FPSO located at the Montara field with tie-backs to the Skua and Swift/Swallow fields via flowlines.

The Montara, Skua and Swift/Swallow oil fields are located in the southern Timor Sea approximately 650km west of Darwin. This section of the Timor Sea is administered by the Northern Territory Department of Primary Industry Fisheries and Mines (NTDPIFM) within Australian territory and is free from any potential issues of sovereignty. The Montara oil field is approximately 82 kilometres south-west of the existing operations at Challis, in about 80 meters of water. The Skua oil field is located 25 kilometres north-west of the Montara oil field and the Swift/Swallow oil field is located 9 kilometres south-east of the Skua field. Coogee owns 100% of Block AC/RL3, which hosts Montara, and the adjoining Block AC/P34, where the satellites are located. The Northern Territory state government has granted environmental approval for Montara and Coogee has submitted a field development plan.

Montara was discovered in the 1980s by BHP Billiton. Skua is an abandoned field that BHP operated for several years before shutting it down in February 1997. Swift and Swallow are finds that Coogee made this year with the semi-submersible drilling rig Ocean Bounty.

The development consists of a floating production, storage and offloading vessel, a mooring system, a wellhead platform, about 60 kilometres of pipelines and umbilicals, plus subsea manifolds and nine producing wells, of which six will be drilled in Phase 1 (currently scheduled to be completed in the third quarter of 2008) and three will be drilled in Phase 2 (currently scheduled to be completed in the third quarter of 2009). Coogee intends to use the FPSO as a hub on its Montara field and tie in the Skua, Swift and Swallow satellites.

Coogee Resources has commenced work on the design, engineering and procurement activities for the Montara Project. Facility construction and development drilling is scheduled to commence in 2007. The platform will be built at a yard in South-east Asia. WorleyParsons is providing engineering services for the platform, while Technip did project concept engineering.

Norway's Advanced Production & Loading (APL) will supply Tanker Pacific Offshore Terminals with a submerged turret system. The $40 million contract is for the provision of a system to be installed on the Montara floating production, storage and offloading vessel in the first half of 2008.

The Montara FPSO is being converted by Tanker Pacific. The 148,255-dwt tanker Freeway will be converted into an FPSO in Jurong Shipyard. Freeway is scheduled to enter the shipyard in the second quarter and will undergo life extension and conversion works, including installation of an internal turret, crude separation, and gas compression and reinjection facilities. On completion in the second quarter of 2008, the FPSO will be named Montara Venture and will be able to handle 40,000 bpd of oil production and store 900,000 barrels.

Vetco Gray was awarded a contract valued at $26 million for the supply of subsea production trees and controls. The contract includes four horizontal trees on mudline (HTOM) systems, wellheads and control systems for subsea control modules, topside controls and subsea distribution and instrumentation. The HTOM systems will be the first ever to be installed in the Asia Pacific/Middle East regions. Scheduled for fast track delivery within 42 weeks, the contract involves VetcoGray facilities in the UK; Singapore and Australia.

Montara has recoverable reserves of 24 million barrels and Skua, Swift and Swallow a combined 15 million barrels. First oil is planned in the third quarter of 2008.

Reindeer / Caribou

The Reindeer/Caribou Field is located in the WA 209P permit in 60 metres of water, 94km offshore northwest of Karratha, Western Australia. Apache Energy is the operator of Reindeer with a 55.0% interest, while joint venture participant Santos owns the remaining 45.0% interest.

The expected gross recoverable reserves at the Reindeer/Caribou field are half a trillion cubic feet of natural gas. Apache plans to develop this field with an objective of first production in 2008. Development options, including the possibility of a new pipeline to the mainland, are currently being evaluated.

Theo-Van Gogh

Apache is progressing with a standalone floating production, storage and offloading vessel on the Theo-Van Gogh discoveries in the deep-water Exmouth sub-basin. The field is in 350m water depth.

The Theo and Van Gogh finds are in a special "pre-defined" area within exploration Block WA-155-P. The owners are operator Apache with a 52.5% working interest, and Japan's Inpex with 47.5%. The Van Gogh oil field has reserves of roughly 59 million barrels, with production forecast to last 12 years. The Vincent oilfield straddles Woodside's Block WA-28-L and Apache's pre-defined area in Block WA-155-P. Woodside and Japan's Mitsui are developing Vincent's 73 million barrels of recoverable oil in Block WA-28-L.

Norway's Prosafe has won a $418 million charter for the FPSO. The contract has a seven-year firm period, followed by options for a maximum of eight years. Prosafe will be responsible for the engineering, procurement, construction, installation, commissioning and operation of the floater. The vessel is expected to arrive in the field in the fourth quarter of 2008. The FPSO will be able to process 150,000 barrels of liquids per day, its crude production has been pegged at 63,000 barrels of oil per day and oil storage will be 620,000 barrels.

The first horizontal well Theo 3-H flowed 9,694 barrels of oil per day. Apache is planning to drill 18 additional long-reach horizontal laterals at Van Gogh later this year. The Theo 3-H well was drilled in 1,205 feet of water to a measured depth of 10,598 feet with a 4,554-foot-long horizontal section in the Top Barrow formation. The test was limited by the capacity of downhole and surface equipment.

Acergy SA was awarded an $85 million contract for installation work. The contractor will be responsible for installing and tying in flowlines, risers, manifolds and a floating production storage and offloading (FPSO) unit mooring. Offshore work will begin in the third quarter of next year. Engineering work for offshore installation and tie-in services will begin immediately from Acergy's heavy construction ship, the Toisa Proteus.

Developing the field will cost roughly $500.2 million, with initial production estimated at 60,000 barrels per day. The project is expected to begin production in April 2009.

Browse

The Browse Gas Project includes the Torosa (formerly known as Scott Reef), Brecknock, and Calliance (formerly known as Brecknock South) discoveries. Combined the fields hold an estimated contingent resource exceeding 20 Tcf of gas and 300 million barrels of condensate. The Browse gas fields are located off the Kimberley coast in water depths of between 400 and 800 metres. Torosa and Brecknock were discovered in the 1970s but have not yet been developed because of their remote location, deep water and lack of a ready gas market.

Woodside is currently investigating options for an LNG development to process gas from the Browse gas fields. Development options cover both an offshore and onshore processing plant. Various potential onshore LNG plant options are being reviewed as well as is an innovative engineering option for doing all of Browse's processing, including CO2 separation, offshore on a bottom-founded gravity base structure-cumartificial island. The two onshore options include a new onshore LNG plant plus associated infrastructure in Kimberley, which requires offshore production facilities and a 300-kilometre subsea pipeline; and Karratha, a 900-kilometre subsea pipeline to the North West Shelf Venture´s onshore LNG hub.

Woodside plans to drill up to four more appraisal wells and shoot two 3D seismic surveys next year. It also plans to finish engineering data gathering, as well as environmental baseline and impact assessment studies, select the development concept and start engineering for the project.

Foster Wheeler and WorleyParsons are carrying out a joint study on an offshore liquefied natural gas facility.

The first cargo from Browse could be delivered from 2011-2014 subject to additional appraisal and customer negotiations. This will require a final investment decision to be made around 2008-2010. Woodside is operator and has a 50% interest in the above permits, except for WA-28-R and WA-29-R where we have a 25% interest. BP, BHP Billiton, Chevron and Shell have varying percent holdings in all blocks.

Ichthys

Inpex Holdings Inc., Japan's largest oil explorer, selected the Maret Islands off Australia's northwestern coast as its preferred site for the liquefied natural gas project. The plant will use Inpex's 100 percent owned Ichthys field in the Browse basin north of Broome about 200 kilometres offshore in water depths between 90m and 340m. The field is estimated to hold more than 9.5 Tcf of natural gas and 312 million barrels of condensates. In September 2006, French operator Total bought 24% stake in the project.

Inpex and Total plan to spend $6.4-8.1 billion on the venture, making it the biggest gas production project headed by a Japanese company. Ichthys Field is planned to be developed as an LNG export project, initially producing approximately 6MTPA of LNG for export. Expansion of the facilities will be determined by market conditions and availability of potential gas reserves in the future. INPEX estimates that Ichthys Field has sufficient gas resources for a production life longer than 30 years. In addition to the LNG production, around 100,000 bbl/day of condensate and LPG will also be produced at the peak rate.

Offshore facilities, including subsea production wells located in and around the field to recover and partially treat gas and condensate
Subsea pipeline, to transmit hydrocarbons from the offshore facilities to an onshore location
Onshore gas treatment and LNG production facilities, including product storage for LNG, condensate and LPG
Loading and handling facilities

Granherne has been awarded a contract to provide field concept screening. The FEED will proceed for one year starting in the fourth quarter of 2007. A final investment decision is due in late 2008.

Subject to obtaining approvals and receiving a production license, Inpex is currently planning for the production of LNG, condensate and LPG to commence approximately mid-2012. The project has recently been granted Major Project Facilitation (MPF) status by the Australian Minister for Industry, Tourism and Resources.

Pilbara LNG

The proposed $A2 billion Pilbara LNG project is undertaking a pre-feasibility study for a liquefied natural gas (LNG) processing plant and export facilities to receive and process feedstock from the Scarborough gas field in the Carnarvon Basin, 280km north-west of Onslow, Western Australia. BHP Billiton has selected a site approximately 4.5kms south-west of Onslow as its preferred location for the LNG plant and export facilities. The project is examining a number of concepts for the field development that would connect to a single train with capacity of approximately 6 million tones per annum. The gas from the Scarborough field is low in carbon dioxide (less than 1 per cent), and is 95 per cent methane and 5 per cent nitrogen. The Scarborough and Jupiter gas fields are believed to contain contingent gas resources in excess of 8 Tcf. Intec Engineering and Granherne provided pre-feasibility support on Scarborough. KBR has been awarded the FEED contract for the Pilbara onshore facilities.

BHP Billiton owns 50% of Scarborough field in permit WA-1-R, the remainder being owned by ExxonMobil (operator). BHP Billiton is 100% owner of the adjacent WA-346-P.

Vincent

Woodside Energy Ltd has approved capital expenditure for its share of the first phase of the Vincent oil field development, off North West Cape in Western Australia. Vincent is about 50km north-west of Exmouth and is in production licence WA-28-L. Vincent will be developed in phases and is subject to government approvals. Oil will be produced through a sub-sea development and processed and stored in a disconnectable, double-hull FPSO. Estimated capital cost for the project’s first phase is about US$720 million (A$1 billion). Woodside has a 60% interest in Vincent and is operator. Mitsui E&P Australia Pty Ltd holds the remaining 40% share.

MAERSK Contractors has won a contract to manage and operate the FPSO for Woodside for seven years over the oil field. It will also design the vessel and manage construction work. Singapore's Keppel Shipyard will convert the 2000-built ultra large crude carrier Ellen Maersk (308,491 dwt) starting early next year and will install the processing facilities, topsides and Maersk-designed mooring system. For the Vincent project, Maersk is working with the Australian Industry Capability Network to maximise local content and will employ 60 engineers during the design and construction phase.

Vetco Aibel has signed a contract with Maersk Contractors for the design, build and start up of the topsides process and facilities modules for the Vincent FPSO. The scope of work for the contract consists of process modules for crude and produced water treatment including water injection system, gas compression and treatment, power generation, utility module, flare system, pipe racks and some minor process packages. Engineering will take place in Billingstad near Oslo, Norway, in Thailand and in Singapore. Fabrication will be done in South East Asia.

Advanced Production & Loading is providing a disconnectable turret mooring system.

FMC Technologies has been awarded an $81 million contract to supply the subsea systems. The work scope includes the supply of 11 enhanced vertical subsea trees, related control and tie-in systems and two production manifolds. Manufacturing and delivery of the equipment will be carried out by FMC's facilities in Kongsberg, Norway and Singapore.

Technip has been awarded the design, engineering, procurement, installation, construction and pre-commissioning umbilicals, risers and flowlines between the Vincent production wells and the project's floating production, storage and offloading vessel. The flexible flowlines will be supplied by Flexi France. The umbilicals will be supplied by Duco in Newcastle, UK. The Venturer will support the offshore operations, which are scheduled to begin in the fourth quarter of 2007. The work will be supported by TS7AP, a joint venture between Technip and Subsea 7 for subsea offshore operations in Asia-Pacific.

Acergy has won a contract worth about $40 million for the transportation and installation of a single-turret buoy system for the floating production, storage and offloading vessel and the installation of a subsea manifold and multi-phase pump structures. The work is scheduled for the third quarter of 2007.

First oil from Vincent is planned for 2008, with initial production of about 100,000 barrels of oil a day.

Pluto

Woodside's 100%-owned Pluto gas field, about 190km north-west of Karratha in Western Australia, underpins the proposed Pluto LNG Project. The current best estimate dry gas contingent resource is 4.1 Tcf. Another field, Xena, which has been discovered in the same permit, has estimated gas resources of 0.4 trillion cubic feet. Development concept for the project includes an offshore platform, deepwater flowlines, a 36" trunkline to shore, up to two LNG processing trains with capacity of five to six million tonnes a year, loading jetty and associated infrastructure. The Burrup Industrial Estate on the Pilbara coast is the selected location for the onshore facilities.

The onshore plant is being designed for two industrial sites just south of the existing North West Shelf Venture which Woodside operates. Industrial Lease Area A, also known as Site A, covers about 60ha and includes the LNG storage tanks. Industrial Lease Area B, also known as Site B, covers about 140ha and includes the major plant and LNG processing facilities. Of the total area of the Pluto leases, plant and facilities will cover about 80ha.

The onshore scope includes a reception terminal including a pig receiver, slug-catcher and MEG (Mono Ethyl Glycol) regeneration facility. Condensate will be stabilised and stored onsite. Light ends will be dehydrated prior to mercury and CO2 removal. The LNG will be transferred to two large insulated storage tanks located on a site adjacent to the main process facilities, and from these storage tanks along a loading jetty onto LNG tankers. Civil works scope consists of site preparation for storage and the plant and dredging of the shipping channel. BGC has been contracted to do site preparation of Industrial Site A.

The FEED for the onshore portion has been awarded to the Foster Wheeler and WorleyParsons consortium. The Foster Wheeler - WorleyParsons group is carrying out studies for an LNG plant using the Shell Global Solutions technology. FWW will also design the utilities for the LNG plant, including power generating capacity in the range of 90 to 120MW.

The Pluto fixed platform will sit in 85m water depth, and comprise topsides weighing some 4000 tonnes plus a substantial jacket. The platform will feature minimal facilities to minimise the operation and maintenance. It will have no processing capability, and will feature multiple risers and J-tubes for production and compression. The platform will act as a hub for gas gathering from other fields. Other facilities might include a bridge connection to a future compression platform. The offshore FEED for the platform and facilities has been awared to the EoS joint venture between KBR and WorleyParsons.

Pluto subsea component comprises of a 180-kilometre 36" export pipeline, seven production wells in water depths of between 400 and 1000 metres, two large manifolds, and about 25 kilometres of flowlines between the manifolds and platform. The trunkline will be routed through Mermaid Sound to a shore crossing at Holden Point. The pipeline will be stabilised by concrete coating and will be trenched or rock dumped for some of its route. The shore crossing will be trenched and backfilled to a level below the minimum tide and will be buried for the onshore section.

The FEED for the subsea trunkline and flowlines has been awarded to J P Kenny. Both onshore and offshore FEEDs are likely to roll over into project management roles. Allseas is set to install the 36" carbon steel trunkline with its giant new pipelay vessel Audacia, which is being built at the Keppel Verolme yard in the Netherlands and is due for delivery in mid-2007. The dynamically-positioned Audacia will be 225 metres in length and 32 metres wide. Pipeline installation will be targeted for late 2009.

Woodside has approved an initial A$1.4 billion (US$1.1 billion) investment, pending a final investment decision by mid-2007. The preliminary commitment will allow contractors to start preparing the site for the project, as well as covering the procurement of long lead time items ahead of Woodside's final decision. The Pluto development will involve capital expenditure of A$6-10 billion. The project will create up to 3000 direct jobs during construction and up to 200 jobs during operations. A further 3000 indirect jobs will also be created, mostly in Western Australia. LNG shipments could begin from late 2010, targeting the Asia-Pacific and North American markets.

Pyrenees

BHP Billiton Petroleum Pty Ltd (BHP Billiton) as operator of petroleum permits WA-155-P and WA-12-R has given the green light to the development of the $2 billion Pyrenees oil project off the coast of Western Australia. The Pyrenees Development consists of five separate fields, these being, Crosby, Ravensworth, Stickle, Harrison and Moondyne. The fields are located in close proximity to each other some 25km northwest of North West Cape, in northern Western Australia. Pyrenees, which is a joint venture between BHP Billiton and United States oil producer Apache Corporation, is expected to produce about 96,000 barrels of oil per day over a 25 year period.

The A$2 billion development includes the purchase of a floating production, storage and offloading vessel and the development of 13 subsea wells tied back to the facility. The water depths across the fields range from 180 to 220m. The development is estimated to contain recoverable hydrocarbon reserves in the order of approximately 20 million m3 (125 million barrels) of crude oil at the most probable (P50) level. The project's surplus gas will be reinjected into an oil-bearing reservoir or another suitable one like the Macedon gas field, which is potentially part of Pyrenees phase two.

Cameron was awarded a contract worth approximately $110 million to provide 13 subsea trees, manifolds and related equipment. Under the contract, Cameron will provide engineering and project management services, 13 wellhead and subsea tree systems, control systems, several subsea manifolds and the associated flowline connection system, chokes and related equipment. Initial equipment delivery and installation is scheduled for the fourth quarter of 2008, with additional deliveries of trees, manifolds and associated equipment to continue through 2010.

The Seastream joint venture between UK-based Wellstream and Dutch workboat company Sea Trucks was awarded a $200 million subsea installation contract covering the supply of 60 kilometres of flexible risers and flowlines, and installation of the entire subsea system including the FPSO turret and mooring system, subsea manifolds, mid-water arches, the flowlines and risers, umbilicals with associated flying leads and the tie-ins to the pre-installed tree flow bases. The Sea Trucks DP3 pipelay/hook-up vessel Jascon 25, scheduled for delivery in April 2008, will undertake most of the offshore installation work. The Pyrenees Development is expected to start production during the first half of calendar 2010.

Angel

The A$1.6 billion project includes installation of the North West Shelf Venture's third major offshore production platform off the North West Shelf and associated infrastructure, including a new 50km subsea pipeline tied in to the North Rankin platform.

WorleyParsons in a joint venture with KBR, has been awarded the Engineering, Procurement and Construction Management contract for the Angel gas and condensate production platform. The subsea engineering of the export pipeline to NRA, tie-ins and flowlines is being performed by J P Kenny. FMC Technologies will supply subsea trees, production controls and associated equipment. The Clough Aker Kvaerner Joint Venture will perform all installation engineering and construction activities related to transportation and installation of the Angel topside module, weighing approximately 7000 tonnes. J. Ray McDermott, S.A. ("J. Ray") was awarded a contract valued at approximately $200 million, for substructure and pipelay installation. The contract will involve transportation of the 7,500MT jacket and piles by J. Ray's launch barge, the Intermac 650, from a fabrication yard in China to the offshore installation site as well as the launch, upend and set down of the jacket. One of J. Ray's marine vessels will install the jacket and pipelines. The project will be managed by J. Ray's office in Perth, supported by its regional headquarters in Singapore. Installation engineering will be supported by J. Ray's marine construction engineering group based in Dubai. The construction of drilling work decks, caissons and other items will be performed at the company's Batam Island fabrication facility in Indonesia.

UK-based offshore accommodation specialist Ferguson Modular was awarded A$2.5 million (US$2 million) contract for the supply of an accommodation complex comprising of the hire of six eight-man accommodation modules plus an office and a medic module, and the purchase of a galley and a food store module. The units will be linked and stacked to form a complex capable of sleeping up to 48 persons on the normally unmanned fixed gas processing platform.

DeepOcean ASA's subsidiary CTC Marine Projects Ltd., has been awarded a contract with a value of over GBP 10 million for the installation of a 51 km power cable linking the existing North Rankin A platform with the new not normally manned Angel Platform. In addition, three umbilicals will be installed to connect the Angel Platform to adjacent subsea production trees. The installation is scheduled to be performed between January and July 2008 and will be managed by CTC Marine Projects and Woodside Energy teams based in the UK and Australia.

Drilling of the three production wells is scheduled between Q3 2006 and Q2 2007. The Angel facilities are expected to be installed and fully operational by Q4 2008.

LNG Phase V

The fifth train is the major component of the proposed LNG Phase V expansion project of the Woodside-operated North West Shelf Venture on the Burrup Peninsula near Karratha in Western Australia. First cargoes of LNG from Train 5 are anticipated by the fourth quarter of 2008. The fifth train will be similar in size and production capacity to the fourth train which can produce 4.4 million tonnes of LNG a year. The expansion project also includes an additional fractionation unit, acid gas recovery unit, boil-off gas compressor, two new gas turbine power generation units, a second loading berth and a new fuel gas system compressor.

The engineering, procurement and construction management (EPCM) contract for the LNG Phase V expansion project to a joint venture of WorleyParsons (25%) and Foster Wheeler (75%). Clough Limited and joint venture partner Interbeton bv have awarded construction of a second LNG loading berth. The jetty extension contract is worth about A$100 million. All construction activities will be performed from the Interbeton supplied IB909 jack up barge. CBI was selected as the mechanical erection contractor for construction of a fifth liquefied natural gas production train.

Downer EDI Limited was awarded a contract for above ground electrical and instrumentation work. The will focus on the new LNG processing train and includes a new load-out jetty, new boil-off gas compressor, acid gas removal unit, new fractionation train and facilities, gas turbine generators and associated switch rooms and auxiliary rooms. Downer Engineering's mobilization at the site has commenced with completion of the contract scheduled for first quarter 2008. The onsite workforce involved in the project is expected to peak between 150 and 190.

Site work started in mid 2005 and the project is expected to take approximately three years to complete with commissioning due to start around mid-2008 and first LNG cargoes planned from Q4 2008. By mid-2007, the project’s construction workforce is expected to peak at up to 1500 people.

The expansion will now cost A$2.425 billion, 21% more than initially budgeted because of escalating construction costs.

Perseus over Goodwyn (PoG)

The project involves the installation of three Perseus sub-sea wells, a Searipple sub-sea well, a new 22km subsea pipeline linking the wells to the Goodwyn platform, as well as a new riser and platform modifications.

Subsea pipeline and riser engineering has been performed by J P Kenny. FMC Technologies are supplying subsea systems including four subsea trees, production controls and associated equipment. The contract value to FMC Technologies is approximately $44 million in revenue. Butting is supplying 16-inch mechanically bonded BuBi® line pipe. DUCO Ltd has been awarded a contract to design, engineer and manufacture the umbilical systems. DUCO’s scope of supply includes 30 km of umbilicals and subsea hardware required to tie-in the PoG, Searipple and SSIV production systems to the Goodwyn Platform. The project will be carried out at DUCO’s dedicated facility in the United Kingdom.

Technip CSO Venturer is expected on location at end November for installation of subsea wells, umbilicals and risers from Perseus-over-Goodwyn to Goodwyn-A platform. Technip has awarded Halliburton a contract to provide pipeline testing and pre-commissioning services. The work will be undertaken by Halliburton's Production Optimisation Division. The two-month contract, starting in November, includes the pre-flooding of spools, riser filling, post tie-in leak testing, bulk dewatering, as well as an option to provide monitoring during pipe lay.

Allseas have been awarded the flowline pipelay, fabrication & installation of in-line tees, survey support and flowline pre-commissioning activities including flooding, gauging and hydrotesting. Pipelay will be done with the Lorelay DP vessel.

The installation of subsea equipment in water depths ranging from 125 m to 134 m is scheduled for late 2006. Perseus over Goodwyn is targeted for completion mid-2007.

Stybarrow

The Stybarrow oil field located in the Exmouth Sub-basin, approximately 65 kilometres from Exmouth, off the north west Australian coast. At a water depth of approximately 825 metres it will be the deepest oil field development ever undertaken in Australia. The Stybarrow project will involve a subsea development and a floating production, storage and offloading facility. The facility will initially produce about 80,000 barrels a day and will have a storage capacity of 900,000 barrels.

Vetco Gray is to supply Horizontal Christmas Trees, Multiplexed Electro-Hydraulic Production Controls and distribution equipment, Remote Connection Systems, and installation tooling and services to BHP Billiton. Bennex under a subcontract to Vetco Gray will deliver five Subsea Distribution Units (SDU) complete with hydraulic tubing, MQC plates, electrical splice boxes with Anguila hoses and connectors. The delivery also consists of nine Infield Subsea Umbilical Termination Assemblies (ISUTA) with a total of 36 Anguila Advanced Cable Terminations (ACT).

Modec is to provide a newbuild FPSO being fabricated at Samsung Heavy Industries in South Korea under a ten-year charter with ten, one-year options. FMC Technologies, Inc. has been awarded a contract for the supply of a turret mooring system for the FPSO. The value of the contract is approximately $62 million. The SOFEC © disconnectable internal turret mooring system will have 12 risers and umbilicals. Toyo Engineering has been awarded supply of the topside processing units. Toyo is responsible for engineering, procurement of equipment and materials, and module fabrication management. The topside modules are scheduled for completion in the third quarter of 2007.

Atwood Oceanic's 5000-foot water depth semi-submersible Atwood Eagle spuded the first of five Stybarrow production wells in September 2006. Three more wells are planned for water and gas reinjection. Development drilling is expected to be completed within nine months Technip and Subsea 7 have won the $160 million subsea engineering, procurement, installation and construction contract for the design, manufacture, transport, installation and pre-commission about 48 kilometres of flexible risers, flowlines and jumpers. The contract also includes the transport, installation and pre-commissioning of about 16 kilometres of dynamic and static umbilicals and associated electrical and hydraulic flying leads, as well as the installation of the floating production, storage and offloading vessel spider buoy and mooring system. Work is expected to start early next year using Technip’s construction vessel Deep Pioneer.

Project costs for Stybarrow are about US$600 million, of which Woodside's share is 50% (about US$300 million). The remaining 50% is held by BHP Billiton (Operator). The Stybarrow project in Western Australia is scheduled to produce first oil in early 2008.

Western Flank

Australia's North West Shelf Venture is progressing with design work on the development of the Western Flank gas fields that will be tied into existing LNG infrastructure. The project includes the collective development of the Dixon, Wilcox, Sculptor and Rankin gas fields, all of which are understood to be within 50 kilometres of the Goodwyn production platform.

Gas and condensate from Goodwyn is exported to the nearby North Rankin platform where a 135-kilometre export subsea trunkline winds its way to the onshore gas plant on the Burrup Peninsula.

Woodside drilled two successful exploration wells on the complex. The Dixon-2 well, located in block WA-9-R about a kilometre east of the Dixon-1 discovery well, intersected a gross hydrocarbon column of around 86 metres. The Pemberton-1 exploration well in block WA-28-P encountered a 65.5 metre gross gas column in good quality reservoir sands in the Mungaroo formation. Block WA-28-P contains the producing Echo/Yodel gas and condensate fields, and is adjacent to block WA-9-R.

The Woodside-operated venture is targeting an investment decision for the Western Flank project in 2008 with first gas in 2011. The likely development concept will be all-subsea with large diameter flowlines from each field linked to Goodwyn.

North Rankin Redevelopment (NR2)

Woodside Energy Ltd as an operator of the North West Shelf Venture (NWSV), together with its six equal participants in the NWSV have began studies on the North Rankin Redevelopment (NR2) which involves the construction and installation of a new platform North Rankin B (NRB) and modification of the process modules of NRA. NRB will be installed alongside NRA with a bridge linking the two platforms.

The prime function of NRB is to provide gas compression and condensate pumping for hydrocarbons produced by the NRA wells, to maintain production and to recover remaining reserves. NRB will extend the life of the North Rankin and Perseus fields to 2041. Following installation of the new NRB platform, the two platforms will function as one production complex.

The NRB topsides will be approximately 20,000 tonnes and will be installed by float over. The deck is supported by a 23,000 tonne eight leg, cross-braced, steel structure jacket with drilled and grouted piles on each corner. The NR2 project also has extensive Brownfield scope as a result of the process/utility ties between the two facilities and major maintenance requirements to meet the extended life of NRA.

FEED and procurement of long lead items for NR2 will begin in the first quarter of 2007. The engineering, procurement management and construction management support services contract for FEED only was awarded to the Eos Joint Venture, an unincorporated joint venture of WorleyParsons Services Pty Limited and KBR E&C Australia Pty Ltd.

Gorgon

The Gorgon project is an LNG facility to be located on Barrow Island in Western Australia, and will include two LNG processing trains, each with a capacity of 5 million tonnes per annum (MTPA). About three shipments a week are expected to leave a dedicated LNG loading jetty.

The subsea gas-gathering system will be located on the sea floor at the Greater Gorgon gas fields west of Barrow Island in 200-1000m water depth. It is anticipated that between 20 and 30 wells would be drilled in the Gorgon area gas fields over a 30-year period. The number of development wells and timing of construction will depend on future gas demand. The key components of the sub-sea gathering system include: development wells, subsea trees, cluster manifolds, pipeline end-manifolds, flowlines, MEG and utility pipeline, two 30-inch pipelines to Barrow Island and a control system including 180km subsea umbilical from Barrow Island to the Jansz subsea manifold. Horizontal directional drilling will be employed to minimise the impact of the shore crossings on local flora and fauna.

It is proposed that much of Gorgon's reservoir carbon dioxide be removed for disposal underground; it will be piped from the processing plant to wells drilled on the island for injection into 2500m deep saline aquifers. The Australian Government made an A$60-million offer to support the efforts of the Gorgon joint venturers to reduce greenhouse gas emissions for the proposed Gorgon project. The offer was to be funded by the government's A$500-million Low Emissions Technology Demonstration Fund, which is designed to address the risk and capital costs of demonstrating low emissions technologies to ensure they are commercially viable in the longer term. The three-year work program for the permit area includes geotechnical studies, 180 km (110 mi) of 2D seismic reprocessing, 1,700 sq km (650 sq mi) of 3D seismic survey acquisition, and the drilling of an exploration well in the additional acreage in permit W06-12. Seismic work will begin this year. There is potential for a further three-year work program in the Carnarvon basin acreage, covering an area of 3,100 sq km (1,200 sq mi) approximately 100 km (60 mi) northwest of the Australian coastline.

J P Kenny Pty Ltd and Technip Oceania Pty Ltd have been selected in a Gorgon Upstream Joint Venture (GUJV) as the front end engineering and design (FEED) and engineering, procurement, construction and management (EPCM) contractor with respect to the upstream facilities for the Greater Gorgon development. FMC Technologies and Vetco Gray are the two shortlisted subsea equipment vendors. Both vendors have performed FEED studies to take their proposed solutions forward and both companies will be included in the tender process.

The Kellogg Joint Venture - Gorgon (KJV-G) including KBR, JGC Corporation of Japan, and Australian-based partners Clough Projects Australia Pty Ltd. and Hatch Associates Pty Ltd have been selected to perform the FEED for the downstream part of the project.

Chevron will delay the final investment decision on the project for at least six months to mid-2007 despite getting the environmental go-ahead for the development from state regulators. The project is now likely to cost more than $16 billion, $5 billion more than first thought.

Chevron is the field operator with 50% equity with Shell and ExxonMobil sharing 25% each for the relevant permits.

The Gorgon project involves the development of a greenfields LNG facility on Barrow Island in Western Australia and two LNG processing trains, each with a capacity of five million tonnes per annum.

The Gorgon Downstream LNG project also includes the installation of a sub-sea gathering system, 70-kilometre sub-sea pipeline from the Gorgon gas fields to Barrow Island, CO2 removal and reinjection process, liquid hydrocarbon shipping facilities to transport the product to international markets, and delivery of compressed domestic gas to the Western Australian mainland via sub-sea pipeline for use by industrial and domestic gas markets.

Mining

Efficiency and Growth Project

Joint venture partners in the Worsley Alumina project BHPBilliton, Japan Alumina Associates and Sojitz Alumina Pty Ltd have begun a full feasibility study to increase production at the Worsley refinery to 4.3 million tonnes a year.

The expansion is based on a $900 million construction project to upgrade the capacity of mining and refinery facilities at Boddington and Worsley. This expansion will be achieved by expanding mining operations within Worsley's lease area, increasing the capacity of the conveyor that carries crushed bauxite from Boddington to the refinery and modifications and upgrades at the refinery.

The site is located approximately 20 kilometers northwest of Collie and approximately 180 kilometers south of Perth, Western Australia. The project is expected to commence in the third quarter of 2006 and will take approximately 24 months to complete.

The joint venture partners have contracted Bechtel Australia Pty Ltd to deliver Engineering Procurement and Construction Management services covering the Feasibility, Transition and Execution phases of the expansion.

Rapid Growth Project 4

BHP Billiton has approved the Rapid Growth Project 4 (RGP4) which will increase system capacity across its Western Australian iron ore operations to 155 million tonnes per annum (Mtpa). Initial production is expected to commence in the first half of CY2010.

BHP Billiton has approved capital expenditure of US$1.85 billion for its share of the project, which includes development of a new crushing and screening plant, as well as additional stockyards, car dumping and train loading facilities at Mt Whaleback. Infrastructure upgrades will also be implemented at satellite orebodies and the rail and port operations. BHP Billiton’s partners in the Pilbara iron ore operations are: Itochu Minerals & Energy of Australia, Mitsui-Itochu Iron and Mitsui Iron Ore Corporation.

Key elements of RGP4 include:

Construction of crushing and screening facilities at Mt Whaleback
Construction of a new car dumper at Mt Whaleback
Construction of a new ore processing plant at Jimblebar
Ore handling plant upgrades at Yandi

Car dumper upgrade at Nelson Point
Construction of a second stockpile row in the East Yard at Finucane Island
Construction of new offices, warehouse and workshops at Finucane Island
General infrastructure upgrades to reduce dust emissions

Additional locomotives
Additional ore wagons
Additional mainline sidings

Fortescue (Cape Preston) Mine and Pellet Plant mining and mineral processing 2000 Dec-07 Dec-10 North West Mineralogy/International Minerals (Wu han Iron & Steel Group Corporation)

Pilbara Iron Ore and Infrastructure Project Fortescue Metals Group Limited will construct rail and port facilities to support the development and sale of the Pilbara's stranded iron ore bodies. Its philosophy is an open third party access regime for other mining users as espoused by the Government. The rail and port assets will be owned by The Pilbara Infrastructure Pty Ltd (TPI) - currently a wholly - owned subsidiary of FMG. TPI includes the mine ore handling facility, railway from Cloud Break to Port Hedland and a port facility at Port Hedland. The key infrastructure parameters include:

-255 kms of railway from Cloud Break to Port Hedland
-4 train sets each comprising 2 locomotives and 200 wagons
-2 berths, a live berth and a lay-by berth designed to handle ships up to 250,000 DWT
-12,500 tph shiploader
-2.4 million tones live stockpile area.

WorleyParson has been appointed the EPCM contractor. The following contractors have been selected for the works:

Jan de Nul NV for the dredging of the port area at Anderson Point.
The vessel CSD "Leonardo da Vinci" has been scheduled for the work.
Metso Minerals (Australia) Pty Ltd for the design, manufacture and commissioning of the train unloader at Anderson Point.
FFE Minerals for the design, manufacture, installation and commissioning of Excel 1100 crushers at the Cloud Break mine site.
BGC Contracting for earthworks and culvert construction along the entire 255km route of the rail line.

The capital cost for the project is estimated at A$1.95 billion. Fortescure is targeting to have the first ore shipped in late 2007.

Jangardup South Mineral Sands Mine mining and mineral processing 40 Jun-10 Jun-12 North West Cable Sands'

Yalgoo Project mining and mineral processing 388.5 Jul-09 Jan-11 Mid West Ferrowest

Kalgoorlie Nickel Project mining and mineral processing 1400 Jul-11 Jul-13

Goldfields
Esperance
Heron Resources

The Perth Seawater Desalination Project comprises the design, construction and operation of a 45 gigalitre per year desalination plant to be located in Kwinana, 25km south of Perth, Western Australia. The project scope includes seawater intake, pretreatment, reverse osmosis desalination, drinking water potabilisation and pumping station. Multiplex is responsible jointly with Degremont for the design and construction of the $387 million plant.

The Project is executed in an Alliance Arrangement with the Water Corporation in two phases covered by separate Design/Construct and Operation/Maintenance contracts. The plant is scheduled for completion by end of April 2007, with potable water supplies being progressively delivered following commissioning in October 2006.

Karara Magnetite Project

The development of the substantial Karara Magnetite Project will bring significant economic and social benefits to the Mid West region, including employment and additional infrastructure and support services opportunities.

Karara will host mining operations for the magnetite iron ore project and is the designated site for a processing plant that will produce high-grade magnetite concentrate.

The unique characteristics of the Karara magnetite deposit include a low level of impurities, the consistency of the orebody and an exceptionally low waste:ore stripping ratio, underpinning cost-competitive mining and processing.

High-grade magnetite concentrate (68.2 per cent iron) will be railed initially to the Port of Geraldton, for export to Yingkou in north-east China, where it will be fed into a 4Mtpa joint venture facility, to produce blast-furnace quality iron pellets. The balance of the concentrate shipped will be purchased directly by AnSteel for its sintering operations.

The interim 1.43 billion tonne Karara magnetite resource, which includes an initial ore reserve measuring 497 million tonnes of 36.3 per cent iron, will support an operation likely to extend over several decades.

Drilling is continuing with the support of AnSteel which is keen to expand production beyond the initial estimated 8Mtpa of concentrate, to support the steel mill's future expansion.

Gindalbie and its Joint Venture partner AnSteel remain on schedule to commence producing both concentrate and pellets in 2010.

Major WA Projects

Oil & Gas

Pluto LNG (Jan 07 - Dec 10)
Location: North West
Company/organisation: Woodside Energy

Van Gogh Oil (Jul 07 - Mar 09)
Location: North West
Company/organisation: Apache/Inpex Alpha

Pyrenees (Jul 07 - Jun 10)
Location: North West
Company/organisation: BHP Billiton

Reindeer/Devil Creek Development Project (Dec 08 - Jun 10)
Location: North West
Company/organisation: Santos/Apache

Mining

Rio Tinto Argyle Diamond Mine (Dec 05 - Dec 10)
Location: North West
Company/organisation: Argyle Diamond

Rapid Growth Project 4 (Mar 07 - Jun 10)
Loation: North West
Company/organisation: BPH Billiton Iron Ore

Hpoe Downs 1, Stage 2 (south) (Nov 07 - May 09)
Location: North West
Company/organisation: Hope Downs Iron Ore, Rio Tinto

Extension Hill Hematite Project (Mar 08 - Mar 10)
Location: Mid West
Company/organisation: Mt Gibson Iron

Worsley Efficiency & Growth Project (May 08 - Dec 10)
Location: South West
Company/organisation: Worsley Alumina

Koolanooka Hardrock Mining Program - Phase 2 (Jun 08 - May 09)
Location: Mid West
Company/organisation: Midwest Corporation

Sino Iron Project (Sep 08 - Dec 10)
Location: North West
Company/organisation: Citic Pacific Mining Management

Sinclair Nickel Mine (Dec 08 - Nov 09)
Location: Mid West
Company/organisation: Xstrata Nickel Australia

Karara Iron Ore Project - Stage 1 Hematite (Mar 09 - Sep 09)
Location: Mid West
Company/organisation: Gindalbie Metals

Karara Iron Ore Project - Stage 2 Magnetite (Mar 09 - Sep 10)
Location: Mid West
Company/organisation: Gindalbie Metals

Balmoral South Magnetite Project (Apr 09 - Sep 11)
Location: North West
Company/organisation: Australasian Resources

Coburn Mineral Sands (Apr 09 - Jun 10)
Location: Mid West
Company/organisation: Gunson Resources

Spinifex Ridge Molydenum/Copper Project (Jun 09 -Dec 10)
Location: North West
Company/organisation: Moly Mines

Balla Balla (Jul 09 -Jul 11)
Location: North West
Company/organisation: Aurox Resources

Blue Hills Hematite Hardrock Mining Program (Sep 09 - May 10)
Location: Mid West
Company/organisation: MidWest Corporation

Southdown Magnetite Iron Ore Project (Nov 09 - Dec 11)
Location: South West
Company/organisation: Grange Resources

Abydos DSO Project (Dec 09 - May 10)
Location: North West
Company/organisation: Atlas Iron

Yannarie Solar Project (Jan 10 - Jan 13)
Location: North West
Company/organisation: Straits Salt

Extension Hill Magnetite Project (Mar 10 - Jun 12)
Location: Mid West
Company/organisation: Asia Iron Ltd

West Pilbara Iron Ore Project (Mar 10 - Jun 12)
Location: North West
Company/organisation: Australian Premium Iron Ore Joint Venture

Keysbrook - Heavy Mineral Sands Mine
Location: Metro
Company/organisation: Olympia Resources

Weld Range Hematite Iron Ore Mine (May 10 - May 12)
Location: Mid West
Company/organisation: Midwest Corporation

Marillana (Jun 10 - Jun 12)
Location: North West
Company/organisation: Brockman Resources

Yilgarn Iron Ore Project (Jun 10 - Dec 10)
Location: Mid West
Company/organisation: Polaris Metals NL

Yalgoo Iron Project (Jul 10 - Jul 12)
Location: Mid West
Company/organisation: Ferrowest Limited

NiWest Nickel Laterite Project (Mar 11 - Dec 11)
Location: Goldfields - Esperance
Company/organisation: GME Resources

Pardoo Magnetite Project (Jul 11 - Jul 13)
Location: North West
Company/organisation: Atlas Iron

Infrastructure

Kwinana Bulk Terminal Handling Infrastructure Upgrade (Jul 04 - Jun 13)
Location: Metro
Company/organisation: Fremantle Ports

Common User Facility Upgrade (May 06 - Jul 09)
Location: Metro
Company/organisation:Landcorp

New Perth - Bunbury Highway (Dec 06 - Dec 09)
Location: South West
Company/organisation: Southern Gateway Alliance

Perth Arena Project (May 07 - Mar 10)
Location: Metro
Company/organisation: Department of housing and works

Cape Lambert Port Expansion (Jan 07 - Dec 08)
Location: North West
Company/organisation: Rio Tinto; Robe River Mining Company Pty Ltd

Alkimos Wastewater Treatment Scheme (Feb 08 - Dec 10)
Location: Metro
Company/organisation: Water Corporation

Greenbushes Intermodal Facility (Sep 08 - Sep 09)
Location: South West
Company/organisation: WA Government, Westnet, Australian Railway Group, WA Plantation Resources, South Spur, Hansol PL

Dampier to Bunbury Natural Gas Pipeline Stage 5B expansion (Jan 09 - Apr 10)
Location: North West / South
Company/organisation: Dampier Bunbury Pipeline

Southern Seawater desalination(Jun 09 - Dec 11)
Location: South West
Company/organisation: Water Corporation

Australian Square Kilometre Array Pathfinder (ASKAP) (Jun 09 - Dec 13)
Location: Mid West
Company/organisation: CSIRO

Power Generation

Bluewaters Power Station (Unit 1 & Unit 2) (Apr 06 - Nov 09)
Location: South West
Company/organisation: Griffin Group

Underground Power Project (UPP) Round 4 (Jan 08 - Jun 11)
Location: Metro
Company/organisation: Western Power

The Neerabup Power Station Project (May 08 - Nov 09)
Location: Metro
Company/organisation: NewGen Power

Albany Bioenergy Plant Stage 1 & 2 (Dec 08 - Dec 10)
Location: South West
Company/organisation: Beacons Consulting International

Centauri 1 Power Station (Feb 09 - Feb 10)
Location: Mid West
Company/organisation: Eneabba Gas

Perth Bioenergy Project (Apr 09 - Apr 11)
Location: Metro
Company/organisation: Spiritwest Bioenergy Pty Ltd

Coolimba Power Project (Dec 09 - Dec 13)
Location: Mid West
Company/organisation: Aviva Corporation

Defence

Amphibious Ships Project (Sep 08 - Jul 15)
Location: Metro
Company/organisation: Defence Materiel Organisation


© Tecside Personnel 2008 \| ABN 94 124 464 393	Designed & Developed by enBIT Pty Ltd

Projects

Oil & Gas

DEVILS CREEK (APACHE Energy)

Blacktip

Blacktip

Crux

Woollybutt South Lobe

Dampier Bunbury Pipeline Expansion

Montara

Reindeer / Caribou

Theo-Van Gogh

Browse

Ichthys

Pilbara LNG

Vincent

Pluto

Pyrenees

Angel

LNG Phase V

Perseus over Goodwyn (PoG)

Stybarrow

Western Flank

North Rankin Redevelopment (NR2)

Gorgon

Mining

Efficiency and Growth Project

Rapid Growth Project 4

Karara Magnetite Project

Major WA Projects

Oil & Gas

Mining

Infrastructure

Power Generation

Defence

Project List